WO2022241567A1 - Procédé de fracturation à plusieurs étages d'un puits géothermique - Google Patents

Procédé de fracturation à plusieurs étages d'un puits géothermique Download PDF

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Publication number
WO2022241567A1
WO2022241567A1 PCT/CA2022/050806 CA2022050806W WO2022241567A1 WO 2022241567 A1 WO2022241567 A1 WO 2022241567A1 CA 2022050806 W CA2022050806 W CA 2022050806W WO 2022241567 A1 WO2022241567 A1 WO 2022241567A1
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WO
WIPO (PCT)
Prior art keywords
formation
conduit
valve
fluid
valves
Prior art date
Application number
PCT/CA2022/050806
Other languages
English (en)
Inventor
Michael Werries
Jesse POWELL
James King
Original Assignee
Ncs Multistage Inc.
NCS Multistage, LLC
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Ncs Multistage Inc., NCS Multistage, LLC filed Critical Ncs Multistage Inc.
Priority to US18/562,792 priority Critical patent/US20240228868A1/en
Priority to EP22803518.4A priority patent/EP4341621A1/fr
Priority to CA3219730A priority patent/CA3219730A1/fr
Publication of WO2022241567A1 publication Critical patent/WO2022241567A1/fr

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/92—Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24T—GEOTHERMAL COLLECTORS; GEOTHERMAL SYSTEMS
    • F24T10/00—Geothermal collectors
    • F24T10/20—Geothermal collectors using underground water as working fluid; using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/001—Cooling arrangements
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24T—GEOTHERMAL COLLECTORS; GEOTHERMAL SYSTEMS
    • F24T10/00—Geothermal collectors
    • F24T10/10—Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E21B34/142—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/10—Geothermal energy

Definitions

  • the invention relates to multistage fracturing of a geothermal well.
  • the invention relates to fracturing the formation using thermally conductive material to improve heat harvesting efficiency in a geothermal operation.
  • Geothermal energy is the thermal energy generated and stored in the Earth.
  • a fluid is typically injected into the ground where it is heated. When the fluid is brought back to surface, the heat can be harvested. This may involve using the heat directly (e.g. to heat homes) and/or to generate electricity (e.g. using a turbine).
  • EGS Enhanced Geothermal Systems
  • fluid is injected down a well into the reservoir under carefully controlled conditions, which causes pre-existing fractures to re-open (and in some cases also creates new fractures within the reservoir), improving reservoir permeability.
  • a working fluid can be injected through the fractured rock, and transported through the reservoir to a production well where the heated working fluid is produced to surface.
  • AGS Advanced Geothermal Systems
  • the operational system may depend on the temperature of the formation, and whether or not the formation already carries a significant quantity of water.
  • Geothermal systems may therefore be open loop or closed loop.
  • a closed loop geothermal system continuously circulates a heat transfer fluid through a sealed downhole conduit. The loop is filled just once and requires only a moderate amount of solution. The fluid never comes in direct contact with the formation.
  • the fluid is directed through the formation to collect heat directly from the rocks.
  • a method of stimulating a formation to facilitate geothermal heat harvesting comprising: providing a conduit within a well, the conduit comprising a series of valves, each valve having one or more ports which are openable to allow fluid flow through a wall of the conduit; performing the following steps for one or more valve of the series of valves, to create a closed loop system within the well: selectively opening a valve of the series of valves; injecting a treatment fluid through the open valve into the formation to open and fill fractures within the formation; and sealing the open valve to prevent further fluid communication between the formation and the conduit via the sealed valve; and with all valves in the closed position, circulating a working fluid within the conduit to harvest heat from the formation.
  • the sealing of the open valve may comprise directly blocking the ports of the valve.
  • the sealing of the open valve may comprise blocking the conduit between the valve and the surface to prevent fluid reaching the ports from the surface.
  • Each of the valves may be stimulated in sequence starting from the valve farthest from the surface.
  • Each of the valves may be selectively controllable (e.g. openable and/or closeable) by dropping a ball or other object into the well which impinges on, and moves, one or more components of the valve to be opened.
  • Each of the valves may be selectively controllable (e.g. openable and/or closeable) using a line from the surface (e.g. coiled tubing).
  • a variety of fluids may be used to create and operate the geothermal well including one or more of:
  • a treatment fluid used to stimulate the formation may include specific types of fluids (e.g. a fracturing fluid for pressure induced fracturing of the formation) and/or multiple fluids injected sequentially into the formation via the conduit;
  • each of these fluids will have a different composition.
  • a fluid of the same composition may be used to perform more than one of these tasks.
  • the same fluid composition may be used as both a treatment fluid to stimulate the formation, and as an annulus fluid to convey materials into the annulus.
  • the method may comprise circulating several well volumes of a cooling fluid to cool the well prior to injecting the treatment fluid at pressures sufficient to fracture the formation.
  • the treatment fluid may be a fracturing fluid.
  • the treatment fluid may be delivered in multiple stages. For example, an initial treatment fluid may be used to generate the fractures, and a second treatment fluid may then be injected comprising a conductive material which displaces the initial treatment fluid and forms a conductive network for conveying heat from the formation to the working fluid.
  • the treatment fluid may comprise a salt which is configured to be molten at downhole temperatures and pressures.
  • the treatment fluid used to fill the fractures during geothermal heat harvesting may have a thermal conductivity of more than 0.6 W/m.K.
  • the treatment fluid may comprise one or more of: tin, bismuth, NaNC>3, KNO3 and Beryllium Oxide.
  • the treatment fluid may comprise one or more of: UNO3, NaN0 2 , KNO2, MgKN, U2CO3, Na 2 C0 3 , K 2 C0 3 , LiF, NaF, KF, MgCI 2 , and KCI.
  • the treatment fluid may consist of non-aqueous materials.
  • the treatment fluid may comprise proppant.
  • the treatment fluid may comprise thermally conductive granular solid (e.g. proppant) in a carrier fluid.
  • thermally conductive granular solid e.g. proppant
  • the method may comprise providing a thermally conductive material within an annulus between the conduit and the well.
  • the thermally conductive material may comprise a thermally conductive granular solid. This may be delivered by recycling an annulus fluid to convey material into the annulus between the wellbore and conduit.
  • a thermally conductive granular solid may comprise one or more of: diamond powder, alumina, aluminium, a thermally conductive ceramic, a thermally conductive element, a thermally conductive metal alloy.
  • the thermally conductive proppant may comprise particles formed of a material with a thermal conductivity of at least 10 W/m.K.
  • the thermally conductive proppant may comprise particles formed of a material with a thermal conductivity of at least 20 W/m.K.
  • the thermally conductive proppant may comprise particles formed of a material with a thermal conductivity of at least 50 W/m.K.
  • the thermally conductive proppant may comprise particles formed of a material with a thermal conductivity of at least 100 W/m.K.
  • the treatment fluid may comprise one or more of: steel beads and conductive nano particles.
  • the treatment fluid may comprise solid granular material at surface which is configured to melt as it is exposed to the heat of the formation.
  • the melting point of the salt may be lower than the temperature of the formation.
  • the formation may be a dry formation. This may facilitate the use of soluble molten salts.
  • the formation may have a temperature of at least 300°C.
  • the formation may have a pressure of at least 30MPa.
  • a treatment fluid e.g. a thermally conductive fluid
  • a treatment fluid may be injected between the conduit and formation prior to stimulating the formation.
  • the method may comprise removing one or more obstructions (e.g. drop balls or darts) in the conduit after stimulation is complete and prior to recycling the working fluid.
  • obstructions e.g. drop balls or darts
  • the method may comprise sealing the valves, and injecting a working fluid the conduit in a closed-loop configuration to harvest heat from the formation and return it to surface without directly contacting the formation.
  • the treatment fluid may be a fracturing fluid configured to create fractures in the formation when injected into the formation under pressure.
  • the treatment fluid may comprise an acid configured to grow fractures within the formation by dissolving portions of rock (e.g. within a limestone formation).
  • an apparatus for stimulating a formation to facilitate geothermal heat harvesting comprising: a conduit, the conduit having a series of valves, each valve having ports which are openable and sealable in sequence to control fluid flow through the wall, wherein in a sealed configuration, each port is sealed using a metal-on-metal seal.
  • a method of stimulating a formation to facilitate geothermal heat harvesting comprising: providing a channel from a surface within a well drilled into the formation, the channel having a wall defining a conduit for carrying fluid, and a series of valves, each valve having one or more ports which are openable to allow fluid flow through the wall; repeatedly performing the following steps: selectively opening a valve of the series of valves adjacent to a region of the formation which has not yet been stimulated; injecting a treatment fluid through the open valve into the formation to stimulate and fill fractures within the formation; and sealing the open valve to prevent fluid passing from the surface to the formation via the sealed valve; and recycling a working fluid through the channel to harvest heat from the formation.
  • a method of stimulating a formation to facilitate geothermal heat harvesting comprising: providing a conduit within a well, the conduit comprising a series of valves, each valve having one or more ports which are openable to allow fluid flow through the wall; providing a thermally conductive material within an annulus between the conduit and the well; performing the following steps for one or more valve of the series of valves, to create a closed loop system within the well: selectively opening a valve of the series of valves; injecting a treatment fluid through the open valve into the formation to open and fill fractures within the formation; and sealing the open valve to prevent further fluid communication between the formation and the conduit via the sealed valve; and circulating a working fluid within the conduit to harvest heat from the formation.
  • the thermally conductive material may comprise a granular solid.
  • a method of stimulating a formation to facilitate geothermal heat harvesting comprising: providing a conduit within a well, the conduit comprising a series of valves, each valve having one or more ports which are openable to allow fluid flow through the wall; performing the following steps for one or more valve of the series of valves: selectively opening a valve of the series of valves; injecting a treatment fluid through the open valve into the formation to open and fill fractures within the formation, wherein the treatment fluid comprises a thermally conductive granular solid; and sealing the open valve to prevent further fluid communication between the formation and the conduit via the sealed valve; unsealing the valves to permit fluid flow between the conduit and the formation; and circulating a working fluid within the conduit and the fractures to harvest heat from the formation.
  • Metal-on-metal seals are particularly useful in high-temperature operations in which other materials (e.g. plastics or elastomers) lose their useful properties.
  • the valves may be considered to be high-temperature valves.
  • the valves and seals may be used at temperatures of 320°C and above.
  • the valves and seals may be used at temperatures of up to 600°C or higher.
  • the treatment fluid may be thermally conductive. Under downhole conditions, the thermally conductive material may have a viscosity greater than that of water. This may help prevent the thermally conductive material migrating away from the conduit after it has been injected.
  • the treatment fluid may comprise a liquid having a viscosity of at least 0.001 pascal-second across a temperature range of 0-320°C (e.g., including above the melting point of the salt).
  • the treatment fluid may comprise a liquid having a viscosity of at least 0.001 pascal-second under steady state formation temperatures and pressures. This ensures that proppant can be supported all the way from the surface to the formation.
  • the treatment fluid may have a heat capacity of more than 1.5 J/g.K.
  • a molten salt used as part of the treatment fluid may have a heat capacity of more than 1.5 J/g.K in a molten state.
  • a molten salt used as part of the treatment fluid may have a heat capacity of more than 1 J/g.K in a molten state.
  • the treatment fluid may be a non-aqueous fluid.
  • the treatment fluid may have a density of at least 1.5g/cm 3 at 20°C and atmospheric pressure.
  • the treatment fluid may comprise molten salt with a density of at least 1.5 g/cm 3 Using a higher density liquid may facilitate carrying particulates such as proppant or conductive particles.
  • the treatment fluid may comprise one or more of: sand and resin.
  • the treatment fluid may comprise a Low Melting Point (LMP) salt (e.g. mixture of 60% NaNC>3 and 40% KNO3).
  • LMP Low Melting Point
  • a low melting point salt may be a salt with a melting point below 350°C.
  • the treatment fluid may comprise a High Melting Point (HMP) salt.
  • a high melting point salt may be a salt with a melting point greater than 350°C and up to 4350°C or higher. The melting point of the salt may be less than the that of the formation.
  • the treatment fluid may comprise Beryllium Oxide.
  • the treatment fluid may comprise metal bead proppant. Using a metal proppant may improve thermal conductivity.
  • the treatment fluid may comprise prills of molten salt or pelletized molten salt.
  • a prill is a small aggregate or globule of a material, most often a dry sphere, formed from a melted liquid.
  • the treatment fluid may be configured to solidify in the fractures within the formation.
  • the formation may be hot.
  • the formation may be at least 320°C.
  • the formation may be less than 600°C.
  • the formation may be a dry formation.
  • a dry formation may not contain significant quantities of water.
  • a dry formation may not contain significant quantities of liquid.
  • the conduit and valves may be formed entirely of metal.
  • the conduit and valves may not comprise plastic or elastomers.
  • Sliding sleeves may be configured to form a metal-metal seal to prevent fluid passing between the sleeves.
  • the conduit may comprise metal packers (e.g. open hole packers).
  • the conduit may comprise a plurality of branches.
  • the conduit may have a fishbone structure.
  • a method for improving heat exchange between a geothermal reservoir and a wellbore comprising: injecting a thermally conductive fracturing fluid into the reservoir at a plurality of locations along a wellbore to improve conduction of heat to the near wellbore region for circulation of a working fluid to collect reservoir heat and bring to surface for energy generation.
  • Figure 1a is a cross-section of a closed-loop embodiment of a conduit configured to fracture a formation at various points along its length.
  • Figure 1 b is a cross-section of the embodiment of figure 1 a after the formation has been fractured, and a pipe has been inserted into the conduit to allow a working fluid to be injected into and recovered from the same conduit.
  • Figure 1c is a cross-section of the embodiment of figure 1a after the formation has been fractured, and the conduit has been connected to another conduit to allow a working fluid to be injected into one conduit and recovered from the other conduit.
  • Figure 2 is a cross-section of an open-loop embodiment of a conduit configured to fracture a formation at various points along its length.
  • Figure 3 is a flow diagram of the method used to fracture a formation.
  • Any geothermal system in which a working fluid is injected into a formation, heated by the formation, and then recovered is limited by the rate at which heat can be transmitted from the formation to the working fluid.
  • the surface area and conductivity of the conduit limits the rate at which heat is transmitted from the formation to the working fluid.
  • the rock itself may restrict the flow of heat by acting effectively as a thermal insulator.
  • One solution to the issue of the inherent low conductivity of the rock formation itself is to create a network of thermally conductive pathways through the reservoir by creating fractures through the formation. This increases the surface area through which heat can be harvested and forms a network of thermal conduits through which heat can be directed to the working fluid when the geothermal system is operational. Even in a closed loop system, the fractures may be filled with thermally conductive material to direct heat towards the working fluid.
  • Figure 1a is a cross-sectional diagram of an apparatus for fracturing a formation in order to facilitate geothermal heat harvesting.
  • figure 1a shows a conduit 100 inserted into place within the well through which fluid can flow from the surface.
  • the conduit comprises a wall 101.
  • the conduit 100 in this case comprises three valves, a proximal valve 102c, a middle valve 102b and a distal valve 102a.
  • Each valve comprises a number of ports 103a- c through the wall of the conduit. When open, these ports facilitate fluid flow through the wall between the conduit and the formation.
  • each valve 102a-c comprises two sleeves: a top sleeve 104a-c and a bottom sleeve 105a-c.
  • the sleeves When the conduit is inserted, the sleeves are in their upper position (i.e. closer to the surface than to the toe of the conduit within their respective range of travel).
  • Each bottom sleeve 104a-c is configured directly to block the ports of the valve when in an upper position, and not block the ports when in the lower position.
  • each top sleeve 105a-b is configured not to block the ports when in an upper position, and directly block the ports when in a lower position. Therefore, the proximal and middle valves have three configurations: an initial configuration when both sleeves are in the upper positions, and the bottom sleeve is blocking the ports; an open configuration when the top sleeve is in an upper configuration and the bottom sleeve is in a lower position; and a resealed configuration when both the top and bottom sleeves are in the lower position, and the top sleeve is blocking the ports.
  • the top sleeve is fixed and does not move in this embodiment. Instead, it provides a fixed seat for a ball which can be used to seal off the ports of the distal valve. It will be appreciated that other embodiments may use a sliding top sleeve in the distal valve or simply have a fixed seat for the ball drop.
  • the first step is to circulate several well volumes of low-temperature fluid (e.g. surface temperature or 20°C or less) through the well to cool the conduit and sleeves.
  • low-temperature fluid e.g. surface temperature or 20°C or less
  • the material of the sleeve may be chosen with a thermal expansion coefficient less than or equal to that of the wall.
  • the sleeves are controlled using successive ball drops.
  • Other embodiments may use darts. It will be appreciated that the sleeves inner diameters may decrease away from the surface such that as larger balls are dropped, each sleeve can be activated in order starting with the farthest one away from the surface, and moving successively towards the surface.
  • Other embodiments may include valves which are controlled using coiled tubing or wireline shifting.
  • the formation is then fractured by injecting a treatment fluid through the distal valve into the formation to fracture the formation and fill the created fractures 110a with the treatment fluid.
  • the treatment fluid in this case is thermally conductive and forms a conductive network of fractures in and around the formation to better harvest heat.
  • the treatment fluid may comprise a conductive molten salt and/or a conductive granular solid (e.g. to act as a proppant).
  • a larger second ball 106y is dropped into the conduit. In this embodiment, the second ball first engages with the bottom sleeve 105b of the middle valve 102b and moves it to a lower position which places the middle valve into an open configuration.
  • the bottom sleeve of the middle valve When the bottom sleeve of the middle valve has been placed in a lower position it releases the ball 106y, and the ball passes through the bottom sleeve 105b to engage with the top sleeve 104a of the distal valve 102a and it stays there without moving the sleeve 104a. That is, the top sleeve 104a acts as a fixed seat for the ball 106y. The ball therefore effectively blocks the conduit and prevents fluid flow from the surface reaching the ports 103a of the distal valve 102a.
  • the proximal valve 104c is in its initial configuration (ports directly blocked by bottom sleeve 105c), the middle valve 104b is in an open configuration (ports open) and the distal valve 104a is in a resealed configuration (ports indirectly blocked by ball 106x).
  • the formation is then fractured at a different location by injecting a treatment fluid through the open middle valve 102b into the formation to fracture the formation and fill the created fractures 110b with a thermally conductive material.
  • an even larger third ball 106z is dropped into the conduit.
  • the third ball first engages with the bottom sleeve 105c of the proximal valve 102c and moves it to a lower position which places the proximal valve into an open configuration.
  • the bottom sleeve of the proximal valve has been placed in a lower position it releases the ball, and the ball passes through the bottom sleeve to engage with the top sleeve 104b of the middle valve 102b, moving it to a lower position where it reseals the ports of the distal middle.
  • the formation is then fractured at a different location by injecting a treatment fluid through the proximal valve 102c into the formation to fracture the formation and fill the created fractures 110c with the thermally conductive material. This is the situation shown in figure 1a.
  • a conduit may comprise more than three valves, and the process could be repeated to fracture the formation at multiple further locations.
  • Other embodiments may have two valves.
  • the balls 106x- z are removed. This can be by flowing them back, dissolving them, melting them (e.g. using the heat of the formation) or milling them out.
  • the first and/or second balls 106x-y at the end of the conduit may or may not be removed. In some embodiments, it may be kept in place to block the end of the conduit, and prevent working fluid entering the formation via the distal valve.
  • a pipe 190 is inserted into the conduit until it approaches the toe forming a coaxial arrangement with the conduit wall.
  • a working fluid e.g. water
  • the working fluid moves through the horizontal section of the conduit it is heated by the formation. Heat is directed to the conduit wall by the fractured network of thermally conductive material within the formation. This heat then passes through the conduit wall 101 and into the working fluid.
  • the heated fluid is then recovered to surface via the pipe. At surface, the heated fluid may be used to power a steam turbine in order to generate electricity.
  • the working fluid may also be circulated in the opposite direction by being pumped into the pipe and recovered via the pipe-conduit annulus. This may allow a pump to be placed within the pipe (e.g. downhole near the surface) to circulate the working fluid, which may be easier to operate.
  • this embodiment is a closed-loop system. Because the conduit was cooled initially, when the conduit is being used in normal geothermal operations, it may be hotter than when it was being used to convey treatment fluids. This hotter temperature may allow the sleeves directly blocking the ports to form an interface fit with the conduit wall around the ports, thereby providing a better seal.
  • the seal may be a metal-metal seal.
  • the pipe and/or conduit may comprise vacuum insulated tubing (VIT) towards the top (corresponding to the cooler vertical portion of the well). This prevents the working fluid being cooled as it approaches the surface.
  • VIT vacuum insulated tubing
  • one well may be connected to another well so that the working fluid can be injected into one well and recovered at another well. This removes the need to accommodate opposing flows within a single conduit portion.
  • An example of this is shown in figure 1c where another well 191 has been drilled to connect with the toe of the conduit.
  • Figure 2 is a cross-sectional diagram of a further apparatus for fracturing a formation in order to facilitate geothermal heat harvesting.
  • figure 2 shows the conduit 200 inserted into place within the well.
  • the conduit comprises a wall 201.
  • the conduit in this case comprises three valves, a proximal valve 202c, a middle valve 202b and a distal valve 202a.
  • Each valve comprises a number of ports 203a-c through the wall of the conduit. When open, these ports facilitate fluid flow through the wall between the conduit and the formation.
  • each valve comprises two sleeves: a top sleeve 204a-c and a bottom sleeve 205a-c.
  • the sleeves When the conduit is inserted, the sleeves are in their upper position (i.e. closer to the surface than to the toe of the conduit).
  • Each bottom sleeve is configured directly to block the ports of the valve when in an upper position, and not block the ports when in the lower position.
  • each top sleeve is configured to not block the ports when in an upper position but, in contrast to the previous embodiment, each top sleeve of the proximal and middle valves 202a-b is configured to restrict flow through the ports when in a lower position. That is, the upper sleeve comprises holes which are smaller than the ports. Restricting the flow allows fluid injected into the conduit to be more evenly distributed across all the valves when harvesting heat from the geothermal formation in an open loop system. In contrast, if the valves are unrestricted, and one fracture has less resistance to fluid flow than the others, fluid will preferentially flow through the low resistance fracture and limit the rate at which heat can be harvested from the formation.
  • the proximal and middle valves 202a, b each has three configurations: an initial configuration when both sleeves are in the upper positions, and the bottom sleeve 205a, b is blocking the ports; an open configuration when the top sleeve 204a, b is in an upper configuration and the bottom sleeve 205a, b is in a lower position; and a restricted configuration when both the top and bottom sleeves are in the lower position, and the top sleeve 204a, b is restricting, but not blocking, the ports.
  • the first step is to circulate several well volumes of low- temperature fluid (e.g. surface temperature or 20°C or less) through the well to cool the conduit and sleeves.
  • low- temperature fluid e.g. surface temperature or 20°C or less
  • first a smallest first ball 206x is dropped in order to lower the bottom sleeve 205a of the distal valve 202a. This changes the distal valve 202a into the open configuration, while the other two valves 202a, b remain closed in their initial position.
  • the first ball 206x also seals off the toe of the conduit.
  • the formation is then fractured by injecting a treatment fluid through the distal valve 202a into the formation to create fractures 110 in the formation.
  • the treatment fluid comprises a thermally conductive granular solid.
  • the thermally conductive granular solid may be act as, or be mixed with, a proppant. In this way, the thermally conductive solid forms a conductive solid network within the fractures to facilitate heat flow from the formation to the working fluid.
  • a larger second ball 206y is dropped into the wellbore.
  • the second ball first engages with the bottom sleeve 205b of the middle valve 202b and moves it to a lower position which places the middle valve 202b into an open configuration.
  • the bottom sleeve 205b of the middle valve has been placed in a lower position it releases the ball, and the ball 206y passes through the bottom sleeve 205b to engage with the top sleeve 204a of the distal valve 202a.
  • the distal valve in this embodiment has a fixed top sleeve 204a which acts as a fixed seat for the ball 206y. With the ball 206y in place, fluid is prevented form passing from the surface into the formation by the ball.
  • the proximal valve 202c is in its initial configuration (ports blocked by bottom sleeve 205c), the middle valve 202b is in an open configuration (ports open) and the ports of the distal valve 202b are blocked by the second ball 206y.
  • the formation is then fractured at a different location by injecting a treatment fluid through the open middle valve 202b into the formation create fractures 210b in the formation. Because the second ball 206y stops fluid passing through the already fractured distal valve, the pressure of the fluid within the conduit is directed towards the middle valve.
  • the treatment fluid comprises a thermally conductive granular solid to help conduct heat within the fractures.
  • the third ball 206z first engages with the bottom sleeve 205c of the proximal valve 202c and moves it to a lower position which places the proximal valve into an open configuration.
  • the bottom sleeve 205c of the proximal valve 202c has been placed in a lower position it releases the ball, and the ball 206z passes through the bottom sleeve 205c to engage with the top sleeve 204b of the middle valve 202b, moving it to a lower position where it restricts the ports of the distal middle.
  • the ball 206z itself prevents fluid flow from the surface to the restricted ports 203b.
  • the formation is then fractured at a different location by injecting a treatment fluid through the proximal valve 202c into the formation to create fractures 210c in the formation.
  • the treatment fluid comprises a thermally conductive granular solid to help conduct heat within the fractures. This is the situation shown in figure 2.
  • a conduit may comprise more than three valves, and the process could be repeated to fracture the formation at multiple further locations.
  • the balls are removed. This can be by flowing them back, dissolving them or milling them out.
  • the first and/or second balls 206x,y at the end of the conduit may or may not be removed. In some embodiments, they may be kept in place to block the end of the conduit.
  • a working fluid e.g. water
  • this embodiment is configured to operate in an open configuration. That is, in this embodiment, this conduit is acting as an injection well. It will be appreciated that this well may be used as a recovery well configured to receive working fluid from the formation and deliver it to the surface.
  • the open loop configuration allows the working fluid to directly contact with the formation, and it can be recovered using another recovery well. As the working fluid is injected, it can pass in and around the thermally conductive granular solid (at either or both of the production and recovery wells) which helps the efficiency of heat harvesting.
  • a thermally conductive granular solid may also be placed around the conduit (e.g. between the valves) to help collect heat directly from the wellbore.
  • the thermally conductive granular solid may be placed around the conduit by injecting an annulus fluid through the open valves prior to or during fracturing (and possibly prior to setting the packers of the conduit).
  • the thermally conductive granular solid may be placed around the conduit by being ejected through an open toe of the conduit prior to fracturing.
  • the conduit of the recovery well may comprise VIT towards the top (corresponding to the cooler vertical portion of the well). This prevents the working fluid being cooled as it approaches the surface.
  • conduit there are a variety of options for installing the conduit.
  • the two embodiments described above each have a closed toe conduit. This means that the conduit can be run into the well and then a setting fluid injected into the well directly to increase the pressure within the conduit and set hydraulic packers which engages with the formation to hold the conduit in place.
  • Another option is to insert an open toe conduit (i.e. where the conduit is open at the distal end). This allows fluid to be removed from the well through the conduit as it is being inserted.
  • a ball or dart or other isolation mechanism is typically inserted to seal the toe.
  • the ball or dart may initially rest in the bottom sleeve of the distal valve. This allows a pressure to be applied within the conduit to set hydraulic packers to secure the conduit to the formation. The pressure may be maintained to confirm set and to perform any required pressure tests.
  • Increasing the pressure further may allow the ball, dart or other isolation mechanism to move the bottom sleeve of the distal valve to open a flow path to the formation and permit fracturing of the formation.
  • thermally conductive fluid can be injected to position a layer of thermally conductive material around the conduit before fracturing is performed. This may be done by injecting the thermally conductive fluid into the conduit and recovering any excess via the wellbore annulus formed between the outside of the conduit and the formation, or by injecting the thermally conductive fluid into the wellbore annulus formed between the outside of the conduit and the formation and recovering any excess from the conduit.
  • FIG. 1 summarizes the method used in the embodiments of figures 1 and 2.
  • a conduit is provided from a surface within a well drilled into a formation, the conduit having a wall defining a conduit, and a series of valves, each valve having ports which are openable to allow fluid flow through the wall.
  • one or more valves are selectively opened while the rest remain closed or blocked from receiving fluid from the surface.
  • a treatment fluid is injected through the one or more open valves into the formation to fracture the formation.
  • the treatment fluid that is used should have a number of properties depending on the type of stimulation (e.g. fracturing or acid stimulation) and the type of geothermal operation (e.g. open or closed loop).
  • type of stimulation e.g. fracturing or acid stimulation
  • geothermal operation e.g. open or closed loop
  • the treatment fluid is configured to conduct heat from the formation towards the conduit to facilitate heat harvesting from the formation.
  • it may be configured to be in a liquid or solid state under downhole conditions. This helps ensure that the treatment fluid remains in place within the fractures and does not migrate away overtime.
  • the treatment fluid may have a thermal conductivity of at least 0.5 W/m.K.
  • the treatment fluid comprises one or more of: steel beads and conductive nano particles.
  • the treatment fluid may be configured to be sufficiently viscous so that it can carry proppant (which itself may be thermally conductive) and other granular materials from the surface into the fractures. This is affected by pumping rate so the rate may be adjusted to ensure that the treatment fluid can support the proppant to the formations.
  • the treatment fluid may be a mixture of granular solids and liquids which can flow within the conduit.
  • the conduit can be connected to another conduit which also provides a pathway to surface. These connected conduits may provide a closed loop circulation pathway for a working fluid to be injected into one conduit and recovered from the other conduit.
  • the conduits may be connection by connecting a horizontal well to a vertical well or by connecting to horizontal wells toe to toe.
  • the conduit may comprise a single surface opening.
  • the working fluid may be injected into the well at this opening and retrieved at the same opening.
  • the conduit may be configured to house an injection portion to inject working fluid into the well and a separate return portion to allow the working fluid to return to the surface. This may be facilitated by having two pipes within the conduit, or using coaxial tubing.

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Abstract

L'invention concerne un procédé permettant d'améliorer l'échange de chaleur entre un réservoir géothermique et un puits de forage. Le procédé comprend l'injection d'un fluide de stimulation dans le réservoir à une pluralité d'emplacements le long d'un puits de forage pour améliorer la conduction de la chaleur vers la région de puits de forage proche pour la circulation d'un fluide de travail pour collecter la chaleur du réservoir et amener la surface à générer de l'énergie.
PCT/CA2022/050806 2021-05-21 2022-05-20 Procédé de fracturation à plusieurs étages d'un puits géothermique WO2022241567A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US18/562,792 US20240228868A1 (en) 2021-05-21 2022-05-20 Method for multistage fracturing of a geothermal well
EP22803518.4A EP4341621A1 (fr) 2021-05-21 2022-05-20 Procédé de fracturation à plusieurs étages d'un puits géothermique
CA3219730A CA3219730A1 (fr) 2021-05-21 2022-05-20 Procede de fracturation a plusieurs etages d'un puits geothermique

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US202163191792P 2021-05-21 2021-05-21
US63/191,792 2021-05-21

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2024044251A1 (fr) * 2022-08-23 2024-02-29 NCS Multistage, LLC Procédés de formation de voies de conductivité thermique accrue pour des puits géothermiques
US11959666B2 (en) * 2021-08-26 2024-04-16 Colorado School Of Mines System and method for harvesting geothermal energy from a subterranean formation

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CA2738907A1 (fr) * 2010-10-18 2011-07-12 Ncs Oilfield Services Canada Inc. Outils et procedes pour la completion de puits
CA2927850A1 (fr) * 2015-04-27 2016-07-15 Sc Asset Corporation Mecanisme permettant de decouvrir successivement des orifices le long d'un trou de forage en vue de l'injection d'un liquide le long dudit trou de forage
WO2016112612A1 (fr) * 2015-01-15 2016-07-21 深圳市百勤石油技术有限公司 Ensemble siège de bille et dispositif de fracturation de type à manchon coulissant à jet de bille
CA3079570A1 (fr) * 2019-09-27 2021-03-27 Ncs Multistage Inc. Injection ou production sur place au moyen d`un puits ayant recours a une operation selective d`ensembles multisoupapes a configurations d`entrebaillement
WO2021101769A1 (fr) * 2019-11-20 2021-05-27 Chevron U.S.A. Inc. Manchons de fracturation et systèmes associés pour des opérations de complétion de fracturation hydraulique à étapes multiples
WO2021119852A1 (fr) * 2019-12-20 2021-06-24 Ncs Multistage, Inc. Opérations de fracturation-à-fracturation asynchrones pour systèmes de récupération d'hydrocarbures et soupapes
WO2021127789A1 (fr) * 2019-12-27 2021-07-01 Ncs Multistage Inc. Systèmes et procédés de production de matériau hydrocarboné à partir de formations non consolidées
WO2022077104A1 (fr) * 2020-10-16 2022-04-21 Ncs Multistage Inc. Ensemble soupape activé par pression de fluide avec restriction d'écoulement et systèmes et procédés pour des opérations in situ
WO2022150925A1 (fr) * 2021-01-14 2022-07-21 Ncs Multistage Inc. Production ou injection in situ par l'intermédiaire d'un puits à l'aide d'ensembles valves actionnés par clapet et procédé et système associés

Patent Citations (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2738907A1 (fr) * 2010-10-18 2011-07-12 Ncs Oilfield Services Canada Inc. Outils et procedes pour la completion de puits
WO2016112612A1 (fr) * 2015-01-15 2016-07-21 深圳市百勤石油技术有限公司 Ensemble siège de bille et dispositif de fracturation de type à manchon coulissant à jet de bille
CA2927850A1 (fr) * 2015-04-27 2016-07-15 Sc Asset Corporation Mecanisme permettant de decouvrir successivement des orifices le long d'un trou de forage en vue de l'injection d'un liquide le long dudit trou de forage
CA3079570A1 (fr) * 2019-09-27 2021-03-27 Ncs Multistage Inc. Injection ou production sur place au moyen d`un puits ayant recours a une operation selective d`ensembles multisoupapes a configurations d`entrebaillement
WO2021101769A1 (fr) * 2019-11-20 2021-05-27 Chevron U.S.A. Inc. Manchons de fracturation et systèmes associés pour des opérations de complétion de fracturation hydraulique à étapes multiples
WO2021119852A1 (fr) * 2019-12-20 2021-06-24 Ncs Multistage, Inc. Opérations de fracturation-à-fracturation asynchrones pour systèmes de récupération d'hydrocarbures et soupapes
WO2021127789A1 (fr) * 2019-12-27 2021-07-01 Ncs Multistage Inc. Systèmes et procédés de production de matériau hydrocarboné à partir de formations non consolidées
WO2022077104A1 (fr) * 2020-10-16 2022-04-21 Ncs Multistage Inc. Ensemble soupape activé par pression de fluide avec restriction d'écoulement et systèmes et procédés pour des opérations in situ
WO2022150925A1 (fr) * 2021-01-14 2022-07-21 Ncs Multistage Inc. Production ou injection in situ par l'intermédiaire d'un puits à l'aide d'ensembles valves actionnés par clapet et procédé et système associés

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11959666B2 (en) * 2021-08-26 2024-04-16 Colorado School Of Mines System and method for harvesting geothermal energy from a subterranean formation
WO2024044251A1 (fr) * 2022-08-23 2024-02-29 NCS Multistage, LLC Procédés de formation de voies de conductivité thermique accrue pour des puits géothermiques

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CA3219730A1 (fr) 2022-11-24
US20240228868A1 (en) 2024-07-11

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